System and method for determining a frequency sweep for seismic analysis

ABSTRACT

A sweep generator is employed to generate a sweep to be used by a seismic vibrator device for generating a desired target output spectrum, wherein the frequency sweep is designed so as to comply with one or more constraints imposed by the seismic vibrator device and/or imposed by the environment in which the device is to be used. In one embodiment, a sweep generator determines a sweep for achieving a desired target output spectrum by a given seismic vibrator device in compliance with at least a pump flow constraint imposed by the seismic vibrator device. In another embodiment, a sweep generator determines a sweep for achieving a desired target output spectrum by a given seismic vibrator device in compliance with all of multiple operational constraints of the seismic vibrator device, such as both mass displacement and pump flow constraints. Environmental constraints may also be accounted for in certain embodiments.

RELATED APPLICATION

This application is a Continuation of co-pending application Ser. No.12/576,804, filed on Oct. 9, 2009, the entire contents of which arehereby incorporated by reference into the present application and forwhich priority is claimed under 35 U.S.C. §120.

TECHNICAL FIELD

The following description relates generally to seismic exploration, andmore particularly to systems and methods for creating frequency sweepsto be used by a seismic vibrator device for generating a desired targetoutput spectrum.

BACKGROUND

In the oil and gas industry, geophysical prospecting techniques arecommonly used to aid in the search for and evaluation of subterraneanhydrocarbon and/or other mineral deposits. Generally, a seismic energysource is used to generate a seismic signal that propagates into theearth and is at least partially reflected by subsurface seismicreflectors interfaces between underground formations having differentacoustic impedances). The reflections are recorded by seismic detectorslocated at or near the surface of the earth, in a body of water, or atknown depths in boreholes, and the resulting seismic data may beprocessed to yield information relating to the location of thesubsurface reflectors and the physical properties of the subsurfaceformations.

Various sources of seismic energy have been utilized in the art toimpart the seismic waves into the earth. As discussed further below,such sources have included two general types: 1) impulsive energysources, such as dynamite, and 2) seismic vibrator sources. The firsttype of geophysical prospecting utilizes an impulsive energy source,such as dynamite or a marine air gun, to generate the seismic signal.With an impulsive energy source, a large amount of energy is injectedinto the earth in a very short period of time. Accordingly, theresulting data generally have a relatively high signal-to-noise ratio,which facilitates subsequent data processing operations. On the otherhand, use of an impulsive energy source can pose certain safety andenvironmental concerns.

Since the late 1950s and early 1960s, the second type of geophysicalprospecting has developed, which employs a seismic vibrator (e.g., aland or marine seismic vibrator) as the energy source, wherein theseismic vibrator is commonly used to propagate energy signals over anextended period of time, as opposed to the near instantaneous energyprovided by impulsive sources. Thus, a seismic vibrator may be employedas the source of seismic energy which, when energized, impartsrelatively low-level energy signals into the earth. The seismic processemploying such use of a seismic vibrator is sometimes referred to as“VIBROSEIS” prospecting. In general, vibroseis is commonly used in theart to refer to a method used to propagate energy signals into the earthover an extended period of time, as opposed to the near instantaneousenergy provided by impulsive sources. The data recorded in this way isthen correlated to convert the extended source signal into an impulse.The source signal using this method was originally generated by anelectric motor driving sets of counter-rotating eccentric weights, butthese were quickly replaced by servo-controlled hydraulic vibrator or“shaker unit” mounted on a mobile base unit. Roughly, half of today'sland seismic data surveys use P-wave hydraulic vibrators for sources.Hydraulic seismic vibrators are popular, at least in part, because ofthe high energy densities of such devices.

Typically, the impartation of energy with vibrator devices is for apreselected energization interval, and data are recorded during theenergization interval and a subsequent “listening” interval. It isdesirable for the vibrator to radiate varying frequencies into theearth's crust during the energization interval. In such instances,energy at a starting frequency is first imparted into the earth, and thevibration frequency changes over the energization interval at some rateuntil the stopping frequency is reached at the end of the interval. Thedifference between the starting and stopping frequencies of the sweepgenerator is known as the range of the sweep, and the length of time inwhich the generator has to sweep through those frequencies is known asthe sweep time.

Vibrators typically employ a sweep generator, and the output of thesweep generator is coupled to the input of the vibrator device. Theoutput of the sweep generator dictates the manner in which the frequencyof the energization signal, which is imparted into the earth, varies asa function of time.

Several methods for varying the rate of change of the frequency of thesweep generator during the sweep time have been proposed. For example,in the case of a linear sweep, the frequency output of the sweepgenerator changes linearly over the sweep time at the rate dictated bythe starting and stopping frequencies and the sweep time. Further,nonlinear sweeps have been proposed in which the rate of change of thefrequency of the sweep generator varies nonlinearly between the startingand stopping frequencies over the sweep time. Examples of nonlinearsweeps have been quadratic sweeps and logarithmic sweeps.

In seismic surveys conducted on dry-land, a seismic vibrator imparts asignal into the earth, where the signal generally has a much lowerenergy level than a signal generated by an impulsive energy source;however, the seismic vibrator can generate a signal for longer periodsof time. Vibrators for use in marine seismic surveying typicallycomprise a bell-shaped housing having a large and heavy diaphragm in itsopen end. The vibrator is lowered into the water from a marine surveyvessel, and the diaphragm is vibrated by a hydraulic drive systemsimilar to that used in a land vibrator. Alternative marine vibratordesigns comprise two hemispherical shells or a curved shell with flatradiating piston, where the two shells are driven by an interconnectedactuator and there is also some form of sealing mechanism between thetwo shells, so that a volumetric source is formed when the vibrator isexcited. The hydraulic actuator moves the two members relative to oneanother in a similar manner to the movement of the reaction mass in aland vibrator. Marine vibrators are therefore subject to operationalconstraints analogous to those of land vibrators. Except where expresslystated herein, “seismic vibrator” is intended to encompass any seismicvibrator implementation, including any dry land or marine implementationthereof.

The seismic signal generated by a seismic vibrator is a controlledwavetrain—a sweep signal containing different frequencies—that may beemitted into the surface of the earth, a body of water or a borehole. Ina seismic vibrator for use on land, energy may be imparted into theground in a swept frequency signal. Typically, the energy to be impartedinto the ground is generated by a hydraulic drive system that vibrates alarge weight, known as the reaction mass, up and down. The hydraulicpressure that accelerates the reaction mass acts also on a piston thatis attached to a baseplate that is in contact with the earth and throughwhich the vibrations are transmitted into the earth. Very often, thebaseplate is coupled with a large fixed weight, known as the hold-downweight that maintains contact between the baseplate and the ground asthe reaction mass moves up and down. The seismic sweep produced by theseismic vibrator is generally a sinusoidal vibration of continuouslyvarying frequency, increasing or decreasing monotonically within a givenfrequency range. Seismic sweeps often have durations between 2 and 20seconds. The instantaneous frequency of the seismic sweep may varylinearly or nonlinearly with time. The ratio of the instantaneousfrequency variation over the unit time interval is defined sweep rate.Further, the frequency of the seismic sweep may start low and increasewith time (i.e., “an upsweep”) or it may begin high and graduallydecrease (i.e., “a downsweep”). Typically, the frequency range today is,say from about 3 Hertz (Hz) to some upper limit that is often less than200 Hz, and most commonly the range is from about 6 Hz to about 100 Hz.

The seismic data recorded during vibroseis prospecting (hereinafterreferred to as “vibrator data”) comprises composite signals, each havingmany long, reflected wavetrains superimposed upon one another. Sincethese composite signals are typically many times longer than theinterval between reflections, it is not possible to distinguishindividual reflections from the recorded signal. However, when theseismic vibrator data is cross-correlated with the sweep signal (alsoknown as the “reference signal”), the resulting correlated dataapproximates the data that would have been recorded if the source hadbeen an impulsive energy source.

In many implementations, vibroseis technology uses vehicle-mountedvibrators (commonly called “vibes”) as an energy source to impart codedseismic energy into the ground. The seismic waves are recorded viageophones and subsequently subjected to processing applications. Today,various sophisticated vibrator systems are available for use, includingminivibes, truck-mount vibes and buggy-mount vibes, any of which may beselected for use in a given application to provide the best possiblesolutions to meet a specific seismic program needs.

It is known in the seismic exploration art that the higher frequenciesof energization signals are attenuated to a greater degree than lowerfrequency energization signals, and most authorities have concluded thatthe attenuation of the earth in decibels is directly proportional to thefrequency of the energization signal. Further, the total attenuation ofany specific signal is known to be dependent upon the velocity,layering, thickness and attenuation coefficients of each layertraversed, as well as the frequency range.

Even though the earth attenuation is known to increase with increasingfrequency of the energization signals, linear sweeps have beenextensively used in vibrators. Techniques for emphasizing the loweramplitude higher frequency responses are well-known and have beenemployed to account for the attenuation applied to these higherfrequency seismic signals by the earth.

Low frequencies (e.g., below 10 Hz) are of interest today due, at leastin part, to increased interest in performing acoustic impedanceinversion. If seismic data can be obtained that is sufficiently quiet,then the acoustic impedance inversion process can be performed, whichmay result in some useful geotechnical information. An additionalbenefit of using low frequencies is that low frequencies penetratefarther than high frequencies, and so their use may permit evaluation ofthe Earth's subsurface at deeper levels. Further, by including some lowfrequency content in the data, it may help improve the continuity ofreflectors and characteristics being imaged in the subsurface underevaluation.

SUMMARY

The present invention is directed generally to systems and methods forcreating frequency sweeps to be used by a seismic vibrator device forgenerating a desired target output spectrum. According to embodiments ofthe present invention, a sweep generator is employed to generate a sweepto be used by a seismic vibrator device for generating a desired targetoutput spectrum, wherein the frequency sweep is designed so as not tocomply with (or “honor”) one or more constraints imposed by the seismicvibrator device and/or imposed by the environment in which the device isto be used. In one embodiment, a sweep generator determines a sweep forachieving a desired target output spectrum by a given seismic vibratordevice in compliance with at least a pump flow (also referred to as“fluid flow”) constraint imposed by the seismic vibrator device. Inanother embodiment, a sweep generator determines a sweep for achieving adesired target output spectrum by a given seismic vibrator device incompliance with multiple constraints of the seismic vibrator device,such as constraints imposed by both the mass displacement and hydraulicpump flow of the device. Thus, in certain embodiments, the sweepgenerator takes into consideration multiple operational constraints ofthe seismic vibrator device when designing a sweep, such as constraintsimposed by the mass displacement and hydraulic pump flow of the seismicvibrator device and/or environmental constraints, to ensure that theresulting generated sweep honors (i.e., does not violate) those multipleconstraints.

Seismic vibrators in use today have constraints that imposefrequency-variant limits on their output amplitude spectrum. Certainconstraints have been recognized in the art. For instance, Sagaini et al(U.S. Pat. No. 7,327,633) have recognized that mass displacement (or“stroke”) of a seismic vibrator device imposes a constraint. However,while a given constraint, such as mass displacement, of a seismicvibrator has been considered when designing a sweep for achieving adesired target output spectrum by the seismic vibrator, suchconsideration of a single constraint fails to take into account otherconstraints that may impose limitations on the sweep, and thus theresulting designed sweep may fail to operate properly when implementedon the seismic vibrator.

Seismic vibrators in use today have various constraints that imposefrequency-variant limits on their output amplitude spectrum. Theseinclude but are not limited to: reaction mass stroke, maximumdeliverable pump flow, hold-down weigh, servo-valve response, availablesupply pressure, and the driven structure response. The problem iscompounded by other effects like absorption of high frequency energy andenvironmental noise. While a conventional linear sweep may work wellenough to image the subsurface given enough sweep time, it may notprovide the most economical solution especially if it requires the useof very long sweep times or many shots at a particular location.According to certain embodiments of the present invention, a sweepgenerator employs a procedure that creates a nonlinear sweep to build upthe sweep spectral density to achieve a target spectrum (that is definedby the user to meet the geophysical survey objectives) in compliancewith (i.e., without violating) various constraints of the seismicvibrator. In another embodiment of this invention, other constraintssuch as environmental constraints (which may be defined by an operatoror derived from prior data about a target location) can be imposed, andthe sweep generator employs a procedure for determining a sweep (e.g., anonlinear sweep) to achieve the target spectrum in compliance with thoseother constraints in addition to or instead of the constraint(s) of theseismic vibrator that are accounted for by the sweep generator. Forexample, when working near populated areas it may be desirable to reducethe instantaneous peak amplitude of the vibrator force through a certainrange of frequencies so as not to excite some structural resonance.Likewise, the sweep generation techniques described herein may beimplemented to compensate for a drop in instantaneous amplitude througha range of frequencies imposed by environmental constraints and asuitable nonlinear sweep may be generated to build up the sweep spectraldensity to achieve a target spectrum. Thus, while many of the examplesdescribed herein provide techniques for determining a sweep thatachieves a target spectrum in compliance with operational constraints ofa seismic vibrator device, such as its fluid flow and/or massdisplacement constraints, the techniques may likewise be employed tofurther ensure that a sweep is determined to achieve the target spectrumin compliance with environmental constraints (e.g., which may be definedby a user).

The amount of energy injected into the earth by a seismic vibratorduring a conventional vibrator sweep is governed by the size of thevibrator and the duration of the sweep. As mentioned above, there areseveral constraints on the amplitude of the vibrations that are imposedby the seismic vibrator device being used. One such constraint is thatthe hold-down weight must exceed the maximum upward force, so that thevibrator never loses contact with the ground.

However, there are other constraints on low frequency output. Asdiscussed above, the ground force is generated by vibrating the reactionmass and the baseplate. The force transmitted to the ground is commonlyestimated using the sum of the reaction mass and baseplate accelerationsweighted by the mass of the reaction mass and baseplate assembly mass,respectively. At low frequencies, the main component to the ground forceis by far that due to the reaction mass since the baseplate accelerationis negligible with respect to the reaction mass acceleration. As such,to generate the same ground force at low frequencies requires greaterpeak velocities and displacements of the reaction mass than for higherfrequencies. Typically, the lowest frequency that can be produced by avibrator at a fixed force level is determined by the maximum strokelength possible for the reaction mass, and the amount of time that theseismic vibrator can dwell at low frequencies is determined by theamount of hydraulic fluid stored in accumulators at the start of thesweep time and the maximum flow capacity of the hydraulic system.

Certain embodiments of the present invention comprise a sweep generatorfor creating a sweep for achieving a desired target output spectrumwhile complying with at least a pump flow constraint of a hydraulicseismic vibrator device. For example, as discussed above it has beenrecognized that the mass displacement of the seismic vibrator device mayimpose a constraint, but prior approaches have failed to recognize oraddress that the pump flow constraint, particularly when operating forlong dwell periods at low frequency, often becomes the more limitingconstraint. So, in certain embodiments of the present invention,multiple constraints are taken into account by the sweep generator whencreating a sweep. That is, multiple operational constraints, such asmechanical and/or hydraulic constraints, associated with a given seismicvibrator device, which limit the output force that can be produced, maybe taken into account. For instance, multiple constraints, such as bothmass displacement and pump flow constraints, of one or more seismicvibrator devices that are under evaluation are taken into account whencreating a sweep for achieving a desired target output spectrum.

In certain embodiments, the sweep generator can receive input ofspecifications of one or more vibrator devices or it may be hard-codedwith those specifications, and it can use those specifications tocompute multiple constraints associated with each device. For instance,it may employ algorithms for computing such constraints as pump flow,mass displacement, etc. over various frequencies. The sweep generatormay receive a desired target output spectrum and create, for the one ormore vibrator devices, a frequency sweep for use in achieving thedesired target output spectrum by such device. In creating suchfrequency sweep, the sweep generator evaluates the computed constraintsfor the device to ensure that the frequency sweep that is createdcomplies with those constraints.

In certain embodiments, the sweep generator may evaluate multiple targetvibrator devices and select a most appropriate one of the devices, suchas one that is most optimal because it can achieve the target outputspectrum by using a sweep that has a duration of a desired time period(e.g., the shortest time period). The sweep generator may be employed asa sanity check to confirm which one or more of the target vibratordevices are operationally capable of achieving the desired target outputspectrum, i.e., confirm which one or more of the devices underevaluation are operationally capable (in compliance with its mechanicalor hydraulic constraints) of supporting a sweep for achieving thedesired target output spectrum.

It should be noted that this provides a quantitative approach. The sweepgenerator, according to certain embodiments, provides the ability topredetermine a sweep that will be known to achieve a target outputspectrum while complying with multiple constraints (or at least the pumpflow constraint) of a hydraulic seismic vibrator device. This differsfrom prior approaches that take into account only a single constraint,such as the mass displacement constraint, but failed to take intoaccount other constraints, such as the pump flow constraint which,particularly for sweeps that include long dwell periods at lowfrequency, may be a more limiting constraint. While the pump flowconstraint was present in the vibrator devices and may have eventuallybeen recognized through trial and error when attempting to implement adesigned sweep on a target seismic vibrator device, embodiments of thesweep generator proposed herein predetermine a sweep that is known toavoid violation of the constraints associated with the target seismicvibrator device. Thus, the resulting sweep designed by the sweepgenerator of one embodiment for achieving a desired target outputspectrum by a target seismic vibrator device is predetermined to complywith at least the pump flow constraint of the device, and is preferablypredetermined to comply with multiple constraints of the device.

The use of measured source signals and ability to control sourcespectral output in both amplitude and phase has led to many innovativeways to dramatically increase acquisition productivity. Over the years,there have been many articles devoted to Vibroseis topics, the vastmajority of which fall into one of two groups: 1) a new sweep method or2) processing issues. The few articles devoted to source engineeringtopics tend to focus on some new feature or a single attribute. Seismicvibrator manufactures are generally good about providing specificationsfor equipment, but oftentimes the geophysicist is not informed on howequipment limitations constrain performance and impact acquisitionobjectives. There have been very few articles in the geophysicsliterature devoted to a concise explanation of how the overall vibratormechanical system typically works, and no proposal for a sweep generatorthat is operable to generate a sweep for achieving a desired targetoutput spectrum on a given seismic vibrator device that is predeterminedto comply with the seismic vibrator device's pump flow constraint, inaddition to complying with other constraints such as mass displacementconstraint.

According to one embodiment, a system comprises a sweep generator devicethat comprises interface logic for receiving input of informationdefining a desired target output spectrum to be achieved by a hydraulicseismic vibrator device. The sweep generator device further comprisessweep generation logic for determining a frequency sweep for achievingthe desired target output spectrum by the hydraulic seismic vibratordevice in compliance with a plurality of different constraints that areimposed by at least one of the hydraulic seismic vibrator device and atarget environment in which the hydraulic seismic vibrator is to beused. In one embodiment, the plurality of different constraints includeat least fluid flow and mass displacement constraints imposed by thehydraulic seismic vibrator device. The fluid flow constraint defines,for a range of frequencies, an operational constraint of the hydraulicseismic vibrator device imposed by its fluid flow, and the massdisplacement constraint defines, for a range of frequencies, anoperational constraint of the hydraulic seismic vibrator device imposedby a stroke distance of its reaction mass.

According to one embodiment of the present invention, a method comprisesreceiving, by a processor-based device, information defining a desiredtarget output spectrum to be achieved by a hydraulic seismic vibratordevice. The processor-based device then determines a frequency sweep forachieving the desired target output spectrum by the hydraulic seismicvibrator device in compliance with at least a fluid flow constraintimposed by the hydraulic seismic vibrator device. The frequency sweepmay be a nonlinear frequency sweep. In certain embodiments, theprocessor-based device determines, based on specifications of thehydraulic seismic vibrator device, the fluid flow constraint that isimposed (e.g., over a range of frequencies encompassed by the desiredoutput spectrum). Thereafter, the determined frequency sweep may beemployed by the hydraulic seismic vibrator device for generating thedesired target output spectrum.

According to one embodiment, a method comprises receiving, by aprocessor-based device, information defining a desired target outputspectrum to be achieved by a hydraulic seismic vibrator device. Themethod further comprises determining, by the processor-based device,based at least in part on specifications of the hydraulic seismicvibrator device, at least a fluid flow constraint imposed by thehydraulic seismic vibrator device, wherein the fluid flow constraintdefines, for a range of frequencies, an operational constraint ofhydraulic seismic vibrator device imposed by its fluid flow. That is,the fluid flow constraint imposes a limit on force that can be generatedby the hydraulic seismic vibrator over a certain range of frequencies.The processor-based device determines a frequency sweep for achievingthe desired target output spectrum by the hydraulic seismic vibratordevice in compliance with at least the fluid flow constraint. In certainembodiments, multiple constraints are taken into account by theprocessor-based device in determining the frequency sweep. For instance,in addition to fluid flow, mass displacement constraint may also bedetermined and taken into consideration. Various other constraints maylikewise be determined and taken into consideration as discussed furtherherein.

The foregoing has outlined rather broadly the features and technicaladvantages of the present invention in order that the detaileddescription of the invention that Follows may be better understood.Additional features and advantages of the invention will be describedhereinafter which form the subject of the claims of the invention. Itshould be appreciated by those skilled in the art that the conceptionand specific embodiment disclosed may be readily utilized as a basis formodifying or designing other structures for carrying out the samepurposes of the present invention. It should also be realized by thoseskilled in the art that such equivalent constructions do not depart fromthe spirit and scope of the invention as set forth in the appendedclaims. The novel features which are believed to be characteristic ofthe invention, both as to its organization and method of operation,together with further objects and advantages will be better understoodfrom the following description when considered in connection with theaccompanying figures. It is to be expressly understood, however, thateach of the figures is provided for the purpose of illustration anddescription only and is not intended as a definition of the limits ofthe present invention.

BRIEF DESCRIPTION OF THE DRAWINGS

For a more complete understanding of the present invention, reference isnow made to the following descriptions taken in conjunction with theaccompanying drawing, in which:

FIG. 1 shows the typical elements of a vibroseis acquisition system,such as may be used for producing an output spectrum according to afrequency sweep that is created by a sweep generator in accordance withembodiments of the present invention;

FIG. 2 shows an exemplary basic circuit of a typical hydraulic seismicvibrator;

FIG. 3 shows a graph illustrating the various constraints and thefrequency bands over which they may be the determining factor, governinghow much force can be realized by a typical hydraulic seismic vibratordevice;

FIG. 4A shows a graph illustrating the theoretical working fluid flowdemand versus frequency for an exemplary seismic vibrator (referred toas “Model A”) while producing a constant fundamental output ground forceof 45,000 pounds;

FIG. 4B shows a cutaway view of a pressure compensated variabledisplacement axial piston pump;

FIGS. 5A-5D show a resulting set of graphs that arise for exemplaryseismic vibrator models, referred to as Models A-D, respectively, whensolving for the maximum peak fundamental force under both the flow anddisplacement constraints;

FIG. 6 shows an example SFC (stroke and flow constrained) nonlinearsweep subject to stroke and flow constraints designed for the case of anexemplary vibrator “Model A” according to one embodiment of the presentinvention;

FIG. 7A shows an exemplary servovalve main-stage (as implemented in theexemplary hydraulic seismic vibrator of FIG. 2), and FIG. 7B shows acorresponding schematic representation of the servovalve main-stage ofFIG. 7A as a bridge circuit;

FIG. 8 shows the peak force constraints over a range of frequencies asdetermined by one embodiment of the sweep generator device for thespecifications of an exemplary seismic vibrator “Model A”;

FIG. 9 shows an example of a desired target output spectrum, which inthis example is shown as a flat spectral density on a linear scale overa range of 3-123 Hz, with a half-power point at 3-Hz;

FIGS. 10 and 11 show graphs illustrating an example sweep designed forthe case of an exemplary vibrator Model A in one exemplary applicationof an embodiment of the present invention, and

FIG. 12 shows the resulting amplitude spectrum;

FIG. 13 shows an exemplary system according to one embodiment of thepresent invention;

FIG. 14 shows an exemplary operational flow diagram according to oneembodiment of the present invention;

FIG. 15 shows the combined restraints that stroke, flow and drive levelimpose on the force output of an exemplary vibrator Model A;

FIG. 16 shows an expanded view of an exemplary normalized targetspectral density profile versus frequency spanning 0 to 10 Hz on alinear scale;

FIG. 17 shows an exemplary cosine taper window function versus time fora 30 second sweep;

FIG. 18 shows the graph of instantaneous frequency versus time for a 30second nonlinear sweep generated to match the target spectral densityobjective;

FIG. 19 shows the signal output of the sweep generator expressed as areference force in Newtons;

FIG. 20 shows the magnitude of the autocorrelation of the sweepgenerator output signal versus time lag on a decibel scale;

FIG. 21 shows the spectral density of the sweep generator output si alversus frequency on a decibel scale; and

FIG. 22 illustrates an exemplary computer system on which software forperforming operations described above for determining a frequency sweepaccording to embodiments of the present invention may be implemented.

DETAILED DESCRIPTION

In order to have realistic expectations of what output is achievablefrom a seismic vibrator, an understanding of the limitations/constraintsimposed by the seismic vibrator machine being used in a givenapplication is essential. Embodiments of the present invention employ asweep development method and tool (or “sweep generator”) that accountfor such constraints in order to make informed choices in the design ofa sweep. According to certain embodiments, the sweep generator receivesinput defining a target output spectrum desired to be produced by agiven seismic vibrator, and the sweep generator designs a frequencysweep for use by the seismic vibrator for achieving the desired targetoutput spectrum, wherein the sweep generator accounts for at least thepump flow constraint of the seismic vibrator to ensure that the designedsweep does not violate that constraint. In certain embodiments, thesweep generator accounts for a plurality of different constraints of theseismic vibrator, such as both its pump flow constraint and massdisplacement constraint, to ensure that the designed sweep complies with(or “honors”) those plurality of constraints.

To aid the reader, the following description is divided into threeparts: 1) a general overview of a typical vibroseis acquisition system,2) a description of typical operation of an exemplary seismic vibratordevice used in vibroseis acquisition and exemplary constraints thatarise in use of such seismic vibrator devices, and 3) description ofexemplary sweep generation systems and methods according to certainembodiments of the present invention, which employ methods and tools fordeveloping sweeps for achieving a desired target output spectrum incompliance with constraint(s) imposed by a seismic vibrator to be usedfor employing a sweep for producing the desired target output spectrum.

Exemplary Vibroseis Acquisition System

The following description first provides a general overview of typicalvibroseis acquisition system. The description is not intended to belimiting on the scope of the present invention, but is instead intendedas an illustrative overview of typical vibroseis acquisition whichprovides a framework for discussion of exemplary application ofembodiments of the present invention. Thus, embodiments of the presentinvention are not limited for use with the specific exemplary vibroseisacquisition system described below, but instead, the concepts describedherein may be readily applied for use with various other types ofvibroseis acquisition systems, both land-based and marine systems, asthose of ordinary skill in the art will recognize.

The system of FIG. 1 illustrates in a simplified manner the typicalelements of a vibroseis acquisition system, such as may be used forproducing an output spectrum according to a frequency sweep that iscreated by a sweep generator in accordance with embodiments of thepresent invention. In the illustrated system, a seismic vibrator 10comprises a vibrating elements: reaction mass with a central bore thatcontains a piston to form a hydraulic actuator 11, a baseplate 12, and asignal measuring apparatus 13 (which is shown in this example asmeasuring signals from two sensors, one on the reaction mass and one onthe baseplate). As one example, signal measuring apparatus 13 maycomprise a plurality of accelerometers whose signals are combined tomeasure the actual ground-force signal applied to the earth by theseismic vibrator. The seismic vibrator 10 illustrated in FIG. 1 isconstructed on a truck 17 that provides for maneuverability of thesystem. An exemplary implementation of the hydraulic system and actuatorfor the seismic vibrator 10 is shown and described further below withreference to FIG. 2. As illustrated in the example of FIG. 1, thehydraulic actuator 11 is coupled with the baseplate 12 to provide forthe transmission of vibrations from the hydraulic actuator 11 to thebaseplate 12. The baseplate 12 is positioned in contact with an earthsurface 16, and the vibrations of the actuator 11 are communicated intothe earth surface 16 via baseplate 12.

The seismic signal that is generated by the actuator 11 and emitted intothe earth, via the baseplate 12, may be reflected off the interfacebetween subsurface impedances Im₁ and Im₂ at points I₁, I₂, I₃, and I₄.This reflected signal is detected by receivers, such as geophones D₁,D₂, D₃, and D₄, respectively. The signals generated by the actuator 11and the baseplate 12 are also transmitted to a data storage 14 forcombination with raw seismic data received from geophones D₁, D₂, D₃,and D₄ to provide for processing of the raw seismic data. In operation,a drive signal, that is an output of the vibrator control electronics,causes the actuator 11 to exert a variable force on the baseplate 12.The vibrator control electronics adjusts the drive signal so that theground force output of the vibrator matches the reference signal asclosely as the system dynamics allow. In most cases, the seismic datareceived from geophones D₁, D₂, D₃, and D₄ is correlated with thereference signal so that the resulting correlated data approximates thedata that would have bee recorded if the source had been an impulsiveenergy so urce.

Further details regarding exemplary vibroseis acquisition systems forwhich embodiments of the present invention may have application areprovided in U.S. Pat. No. 7,327,633 titled “Systems and Methods forEnhancing Low-Frequency Content in Vibroseis Acquisition”, U.S. Pat. No.4,512,001 titled “Method and Apparatus for Seismic Exploration UsingNonlinear Sweeps”, and U.S. Pat. No. 4,680,741 titled “Method andApparatus for Seismic Exploration Using Non-Linear Sweeps”, thedisclosures of which are hereby incorporated herein by reference.

Exemplary Seismic Vibrator Device and Constraints that Arise in UseThereof

The following description provides a general overview of typicalhydraulic vibrator devices, which are commonly employed as actuator 11in vibroseis acquisition system 10 (of FIG. 1). The description of thehydraulic vibrator device provided below is not intended to be limitingon the scope of the present invention, but is instead intended as anillustrative overview of typical hydraulic vibrator devices whichprovides a framework for discussion of exemplary application ofembodiments of the present invention. Thus, embodiments of the presentinvention are not limited for use with the specific exemplary vibratordevices described below, but instead, the concepts described herein maybe readily applied for use with various other types of vibrator devices.

An exemplary basic circuit of a typical hydraulic seismic vibrator 200is shown in FIG. 2. Hydraulic seismic vibrator 200 includes an engine201, which is typically a diesel engine that runs at a constant RPM(revolutions per minute), turning a variable displacementpressure-compensated piston pump 202 that supplies the flow of hydraulicfluid 203, which flows according to the arrows shown. Every revolutionof the engine 201 generates a certain amount of flow. Accordingly, ifthe pump 202 were implemented as a fixed displacement pump, the amountof flow would remain constant. However, because when a frequency sweepis desired the flow demand changes over time, a variable displacementpump 202 is typically implemented. As discussed further hereafter withFIG. 4B, within the variable displacement pump 202, there is typically aswash plate (shown as swash plate 401 in FIG. 4B) that is coupled topistons (shown as pistons 402 and 403 in FIG. 4 b). By moving the swashplate, the amount that the pistons move in each revolution of the engine201 can be varied. Therefore, pump 202 can vary the flow that itproduces even though the engine RPM that is driving the pump shaft isgenerally constant.

Typically, a high pressure cylinder 206 that acts similar to a hydraulicactuator is implemented. Such cylinder 206 is sensitive to pressure, andit drives the stroke arm 207 on the pump 202. Consider for example thatthe cylinder 206 is set to 3,200 psi, and there is a large flow demand;over time, the pressure may start to drop in the system. Cylinder 206will sense that drop in pressure, and it will move the stroke arm 207 onthe pump 202 to increase the displacement of the pump per revolution,thereby creating more flow and increasing the pressure.

Following the arrows exiting the pump 202, passageways (e.g., hoses) 204connect the pump's output through a filtration system 205 to theservovalve 209 that is under the control of the vibrator electronics(not shown for simplicity and ease of illustration). Filtration providedby the filtration system 205 removes particles that may slough off overtime from hose interiors, seals or created by cavitations. Filtrationsystem 205 might be two-micron or three-micron filters, for example,because the clearances inside the servo valves 209 are generally on theorder of 1/10,000^(th) of an inch or 2/10,000^(th) of an inch.

Then there is a high pressure accumulator 208 which is implemented toremove any ripples or pressure spikes in the supply flow, either due tothe changes in demand or pump noise. So, the accumulator 208 effectivelyacts similar to a filter capacitor on an electrical power supply, and itis an energy storage device too.

Then the flow goes into a servo valve 209, which is often implemented asa four-way valve. Typically, servo valve 209 includes a spool valve 210as the main stage. The servo valve itself ordinarily is actually athree-stage valve, and a small torque motor operates a small flappervalve. It takes very little current to cause this torque motor to movefor in turn moving the flapper valve. When it moves (maybe you get aquarter of a gallon per minute for the maximum flow out of that), andthat flow then goes into a small spool valve, another four-way valve.So, there is some hydraulic amplification. Then the output of thetwo-stage pilot valve is probably about a five gallon per minute peakflow. That flow then moves the ends of a third stage. It drives the mainstage spool back and forth. So, as the valve moves back and forth, it isa proportional valve and it basically acts like a giant resistor. Sinceit is a four-way valve, it acts similar to a four-armed bridge circuitwith a resistor at each arm of the bridge and the load connected acrossthe horizontal nodes of the bridge. In this instance, the hydraulicpower supply is connected across the upper and lower junctions in thisbridge.

The flow that comes from the servo valve mainstage 210 is used to drivethe reaction mass 218. Let us assume that the servo valve mainstagespool 210 is in such a position that the high pressure is ported throughthe “Upper Passage” in FIG. 2 and into the upper chamber of the mass218. That flow then causes the mass 218 to accelerate upwards and at thesame time there is an equal and opposite reaction force that goes to thepiston that is inside the hydraulic actuator that is connected to abaseplate 211 that is in contact with the earth (e.g., which is the sameas baseplate 12 of FIG. 1), and then pushes on the earth creating thedesired seismic energy. A hold-down system (not shown) is applied to thebaseplate 211 to maintain good contact of the baseplate 211 with theearth while it is dynamically driven. At the same time that the valve210 is open to the upper chamber, it also connects to the lower chamberof the reaction mass through the “Lower Passage” in FIG. 2 to the returnpressure. If the upper chamber is pressurized, the mass 218 moves up andthe exhaust flows out of the lower chamber. This is commonly referred toas a double acting cylinder, and the reaction mass 218 effectively actslike a double acting cylinder. The fluid 203 exiting through the lowerchamber returns back through the servo valve 210 and then eventuallygoes back to the pump 202.

Accordingly, for the servovalve spool position shown in the example ofFIG. 2, the flow drives the reaction mass (MR) 218 upward therebycreating a reaction force that is applied to a piston that is coupled tothe earth through the baseplate (MB) 211 and driven structure. At thesame time, the fluid 203, which is metered into the upper chamber, exitsfrom the lower chamber back through the servovalve main stage 210 andreturns to the pump intake. Thus, the servovalve 209 offers proportionalcontrol and meters the working fluid 203 as it enters and exits thehydraulic actuator. (The pilot stage of the servovalve 209 is notdepicted.)

A low pressure accumulator 212, as well as a low pressure filter 213,and oil cooler 214 are also typically included in that return path.There is also a reservoir tank 215 that holds the hydraulic fluid 203.Because these cylinders are designed to last many, many, millions ofcycles, seals typically will not hold up with that kind of usage,particularly since the seals are trying to seal against fairly highpressures. So, things are generally not hermetically sealed, so tospeak, and so usually the ends of the mass actuator are ported back tothe reservoir tank 215. There are generally some wiper seals or bushingson the ends of the mass such that this leakage flow is ported back tothe reservoir tank 215 at atmospheric pressure, where the seals onlyhave to seal against the atmospheric pressure. There is a small primepump (or “make-up pump”) 216 that is typically driven by an electricmotor 217, to supply fluid from the tank 215 to the return side in theinlet of the main pump 202, which makes up for the above-mentionedleakage.

The hold-down force is typically provided by the vehicle weight and isapplied through a system of airbags. The airbags isolate the vehicleframe (e.g., of the truck 17 shown in FIG. 1) from the baseplate 211usually for frequencies at and above about 2-Hz. The resulting contactforce at the baseplate/earth interface, called ground force, is thesignal most commonly used to represent the system output, with thepolarity convention that a positive ground force indicates compression.

Ground force is typically approximated using the mass weighted sum ofthe reaction mass and baseplate accelerations. In the absence of shearstress at the contact surface, the far-field particle displacementdownhole, due to P-wave radiation from an acoustically small discvertically oscillating at the surface, in the theoretical world ofelastic isotropic half-spaces, has the same spectral shape except fortime delay as the ground force. For small sources, it can be shown thatthe distribution of the vertical stress applied over the contact areaneed not be uniform and that the same relationship holds between theresulting ground force and far-field particle motion. Geophones velocitytransducers), such as those shown as D₁-D₄ in FIG. 1, are generally usedas receivers.

Thus, in an elastic isotropic homogeneous half-space far-field particlevelocity or pressure due to the radiated compression wave isproportional to the time derivative of the applied vertical force exceptfor time delay, and inversely proportional to the distance traveled. Inmost cases the best we can do is to maintain a flat force output that isbelow the hold-down force applied. For the case of a linear sweep, wewould expect to see a +6-dB/octave rising spectrum in measured particlevelocity or +12-db/octave rising spectrum if accelerometers are used asreceivers, but in reality the earth is not elastic and absorptionattenuates these high frequencies very quickly.

The spring/dashpot 220 shown in FIG. 2 form a simple half-space model ofthe earth radiation impedance when working on hard surfaces. A morecomplete model for the earth, particularly when working on mud or sand,might include an effective captured ground mass. For a layered medium,the radiation impedance model becomes much more complicated, where thevibrator “sees” the effect of shallow reflectors and this too affectsthe driving point impedance. In the real world, where baseplate supportis not even and the medium is neither homogeneous nor linear, couplingissues can add considerable complexity to any model of impedance. Othermajor components not fully shown in FIG. 2, but which are well known tothose of ordinary skill in the art, include the hold-down/lift/isolationsystem, mass-centering suspension and driven structure. Inclusion of theelectronic feedback control and telemetry system (not discussed indetail herein, but which are well known to those of ordinary skill inthe art), complete the picture.

Seismic vibrators in use today, such as the exemplary hydraulic seismicvibrator represented by FIG. 2 discussed above, have constraints thatimpose frequency-variant limits on their output amplitude spectrum. Thatis, operational constraints, such as mechanical and hydraulicconstraints of the hydraulic vibrator, impose frequency-variant limitson the output amplitude spectrum achievable by the hydraulic vibrator.These constraints include but are not limited to: reaction mass stroke,maximum deliverable pump flow, hold-down weight, servo-valve response,available supply pressure, and the driven structure response. Theproblem is compounded by other effects like absorption of high frequencyenergy and environmental noise. While a conventional linear sweep maywork well enough to image the subsurface given enough sweep time, it maynot provide the most economical solution especially if it requires theuse of very long sweep times or many shots at a particular location.

FIG. 3 shows a graph illustrating the various constraints and thefrequency bands over which they may be the determining factor, governinghow much force can be realized by a typical hydraulic seismic vibratordevice. That is, FIG. 3 illustrates the constraints imposed by thetypical hydraulic seismic vibrator's hydraulic and mechanical system,and shows at what frequency range(s) each constraint typicallycompromises the force output amplitude achievable by the seismicvibrator. As shown in FIG. 3, such constraints imposed by the seismicvibrator's hydraulic and mechanical systems that may govern how muchforce can be output by the seismic vibrator over different frequencyranges may include fluid flow, lift isolation, mass stroke (or“displacement”), hold down, pilot valve, driven structure, and supplypressure. These constraints can be important to consider when designingsweeps for practical implementation. These constraints and furtherdetails regarding how they affect the output response are describedbelow.

Flow Constraints of the Hydraulic Circuit

FIG. 4A shows a graph illustrating the theoretical working fluid flowversus frequency for an exemplary seismic vibrator, referred to hereinas “Model A,” such as that equipped with a pump like that represented inFIG. 4B. The theoretical working flow refers to the flow that an idealpump of infinite capacity and perfect pressure regulation would have toprovide to meet the load requirement of the vibrator while maintainingthe prescribed target force. FIG. 4A shows this flow for a vibratoroperating on sand or chalk when delivering a constant fundamental-peakground force output of 200-kN (45000 pounds) for a 5-200 Hz sweepsubject to a raw peak force limit of 267-kN (56000 pounds) correspondingto 90 percent of hold-down. The overall raw peak force limit of 267-kNin this example is to ensure that the baseplate does not completelydecouple from the ground.

At low frequency due to harmonic distortion, the raw ground force signaltends to look like a triangle wave, the implication being thefundamental output falls below 200-kN for frequencies less than 15-Hz,since the peak force levels approach the 267-kN threshold. So, forexample, on sand at 10-Hz the ground force waveform may have a raw peakvalue of 267-kN, with a fundamental peak value of only 155-kN. The peakflow demand ranges from close to 946-1/min (250-gpm) at low and highfrequencies to less than 57-1/min (15-gpm) at resonance (low points onthe curves of FIG. 4A). That vibrator pump only has a rated flow of 605l/min (160-gpm) (as indicated by the “Pump Rated Flow” line in the graphof FIG. 4A) and this imposes a constraint particularly for low-frequencydwell sweeps (where, as shown in the graph, the flow demand exceeds thisconstraint). Above this resonance, flow demand increases with frequencyprimarily due to the compressibility of the hydraulic fluid. A lot offlow is wasted “squeezing the fluid” rather than moving the reactionmass and driven structure. As frequency increases the rate of thiscyclical compression of the trapped fluid volume increases creating ahigher flow demand with more power wasted as heat.

Because pumps are flow devices and the engine RPM is constant, in orderto maintain a constant pressure the volume of flow delivered perrevolution must change. FIG. 4B shows an exemplary representation of atypical pump interior (e.g., an exemplary implementation of a pump 202of the exemplary seismic vibrator hydraulic circuit of FIG. 2). Thepump's flow output is changed as the swash plate 401 is tilted to varythe maximum displacement of each piston 402, 403 in the pump perrevolution. The swash plate 401 is controlled by a hydraulic cylinder404 inside the pump. The pump has its own closed-loop-feedback system.As flow demand increases, the system pressure falls. The fall inpressure causes a hydraulic actuator to change the pump displacement viathe swash plate 401 to increase flow and thereby build pressure. Theresponse time of pumps to changes in demand varies with manufacturerfrom between 100-700 ms to go from no flow to rated flow and between35-50 ms to go from rated flow to no flow. So, pumps in use today onlarge seismic vibrators are not fast enough to respond to rapidfluctuations in demand that can occur within certain designed sweeps.Accumulators, such as accumulator 208 of FIG. 2, help to maintain systempressure when flow transients occur.

As mentioned above, there is an increasing interest in increasing thelow-frequency content of sweeps. One constraint that is often taken intoaccount is the mass stroke (or “displacement”), which limits the forcethat can be generated at low-frequency before the mass hits its stops.

As discussed herein, another limit is the pump flow (or “fluid flow”) ofa hydraulic seismic vibrator device. For most vibrators in use today,pumps are incapable of delivering adequate flow forlong-dwell-low-frequency linear sweeps even at reduced drive levels.This flow limit typically comes into play if the dwell-time for afrequency below about 8-Hz exceeds 2-s and the vibrator is being drivennear its maximum achievable output. This guideline is based on anassumption that most large vibrators have typically 10 to 20-liters ofhigh pressure accumulator capacity, let's assume 15-liters. If the pumpsupplies a maximum average flow of 10 liters/s and generation of 6-Hzrequires an average flow of 13-liter/s, the flow deficit is 3-liter/sthat must be supplied by the accumulators. One might think that such asystem can operate for 5-s without running out of hydraulic fluid (or“oil”) (15-liters/3-liter/s), but because the system pressure falls asthe accumulators are depleted, the system is not left with adequatesupply pressure to maintain the high target force and most likely theresult will also create lots of distortion. To be safe, operatorsgenerally prefer to avoid flow demands that exceed pump capacity formore than 2-s. The first symptom one encounters is the inability tomaintain system pressure throughout the sweep or an alert of valveovertravel.

Thus, reaction mass stroke and pump capacity can limit low frequencyoutput. Thus, an approach that takes into consideration only thereaction mass stroke (or displacement), as in the MD method discussedfurther below, is insufficient. Accordingly, certain embodiments of thepresent invention, as discussed further below, provide a unifiedapproach that takes into consideration multiple constraints, such asflow and reaction mass stroke in designing a sweep (e.g., a non-linearsweep) for achieving a target output spectrum. Under some simplifyingassumptions, some conservative estimates for the peak fundamental forcethat can be determined subject to both flow and stroke constraints canbe developed. The underlying assumption is that at low-frequency (lessthan 10 Hz) the reaction mass moves much more than the baseplate and sothe baseplate motion can be ignored. (See formula box, “Formula Box 1,”below.)

The flow and displacement constraints may be combined to solve for themaximum peak fundamental force (F_(pk)) a given hydraulic seismicvibrator device might be able to sustain under those constraints. FIGS.5A-5D show a resulting set of graphs that arise for exemplary seismicvibrator models referred to herein as Models A-D, respectively, whensolving for the maximum peak fundamental force under both the flow anddisplacement constraints. The vibrator specifications, which were usedto determine curves in FIGS. 5A-5D are are shown in Table 1 below. Solooking at FIG. 5A, the parabolic shaped dashed line represents themaximum force that can be realized due to a displacement limit. In thiscase, this displacement limit provides only an overiding constraint tooutput force form the range of zero to 3.8 Hz and this portion of thesolid curve is labeled stroke limited. For frequencies above 3.8 Hz thedisplacement limit is no longer the dominate factor. So, looking againat FIG. 5A, the force output of the Model A vibrator might beconstrained by pump flow over the range of 3.8-Hz to 8-Hz with thisportion of the curve labeled as “FLOW LIMITED”. As we move higher infrequency to above 8 Hz the overiding limiting factor is the force “SETPOINT” that the user has selected that corresponds to the maximum forceoutput to be employed in the sweep. The Model B with the same pump, samepiston area, and a larger mass is limited by flow over the range of3.8-Hz to 5.3-Hz, but is capable of generating considerably more forceover that band of frequencies than the Model A, as illustrated in FIG.5B.

TABLE 1 Stroke_(useable) Pump_flow_rating Model F_(h) (N) M_(r) (kg)A_(p) (m²) (m) (m³/s) Model A 266900 3691 .01329 .1020 .01009 Model B266900 5696 .01329 .1020 .01009 Model C 278000 4082 .01334 .0762 .00763Model D 356000 7000 .01570 .1020 .01055

Exemplary Sweep Creation Systems and Methods According to CertainEmbodiments of the Present Invention

To some extent nonlinear sweeps, and in particular low-dwell sweeps, canbe designed to compensate for the lack of output force that can beachieved at low frequencies. A brief discussion of the constraintsimposed by the vibrator response in combination with earth absorption ofhigh frequency energy and illustrates how nonlinear sweeps could bedesigned to help compensate for both the vibrator and earth response isprovided in Anstey. N. A., 1991. Vibroseis, Prentice Hall, EnglewoodCliffs, N.J., 114-124. As was mentioned earlier, because the earth isnot a pure elastic medium (aborption can quickly eat up high frequencygains) and due to economic constraints, the boost in spectral contentafforded by the use of nonlinear sweeps can be quite limited. Rietsch(1977a, 1977b) derives the relationship between the sweep rate and powerspectrum in: Rietsch, E., 1977a, Computerized analysis of vibroseissignal similarity, Geophysical Prospecting, 25, 541-552, the disclosureof which is hereby incorporated herein by reference. Rietsch thenpresents a recursive algorithm for creating nonlinear sweeps with adesired target spectrum in: Rietsch, E., 1977b, Vibroseis signals withprescribed power spectrum. Geophysical Prospecting, 25, 613-620, thedisclosure of which is hereby incorporated herein by reference.

More recently, Bagaini et al (U.S. Pat. No. 7,327,633) propose a methodreferred to as (Maximum-Displacement or “MD” sweep design), which takesinto account some vibrator constraints to deliver a user definedground-force spectral density (or “a desired target output spectrum”).The MD sweep design considers two basic constraints at low-frequency:mass displacement and harmonic distortion content (the harmonicdistortion is empirically determined in the MD method and will generallybe a function of: 1) drive level; 2) earth coupling; and/or, 3) vibratorcontrol electronics). The MD method will tend to overestimate force thatcan be realized when low frequencies must be sustained due to the factthat the vibrator pump is unable to meet the flow demand of sustainedlow frequencies. A method referred to herein as SFC (Stroke FlowConstrained sweep) can be determined for generating a low-dwell sweepthat enables the low-frequency energy to be increased.

We now briefly discuss this SFC method, as well as how one mightcompensate for the vibrator response in such method. Assume that: “f”represents the instantaneous frequency (Hz) in the sweep,“F_(target)(f)” represents the target source spectrum (N),“F_(constraint)(f)” represents the maximum force constraint (N), for agiven sweep length SL (s) with start and end frequencies F0 (Hz) and F1(Hz) respectively we find the modified instantaneous sweep rate “SR(f)”(Hz/s) will be:SR(f)=β[F _(constraint)(f)/F _(target)(f)]² [F1−F0]/SL  (3).

The parameter “β” is a constant of proportionality that will be afunction of the deviation away from a conventional linear sweep that isto be employed. In certain embodiments, a sweep generator deviceincludes logic that employs the above equation (3) so that it modifiesthe sweep rate to be used in a sweep that it is generating in order todetermine a sweep that achieves a desired target output spectrum incompliance with at least the fluid flow and mass displacementconstraints of a given hydraulic seismic vibrator device. The sweep ratefor a particular frequency is related to a constant of proportionality(i.e., “β”) times whatever the constraint is determined to be at thatfrequency (which may be determined as a minimum of various equations fordetermining a plurality of different constraints, such as those shown inFIG. 3, which may be determined via equations discussed further hereinand/or otherwise known in the art), divided by the target spectrumsquared, then multiplied by a scale factor (e.g., F1 might be the endfrequency and F0 the start frequency of a sweep), then divided by thelength of time of the sweep, i.e., the sweep length (SL).

The constant of proportionality, “β,” is generally not known at theoutset of determining the sweep by the sweep generator. One techniquefor determining β is to run this program twice. In the first run, β maybe set to a given value, say β=1. Then, based on an evaluation of theresult of the first run, it may be determined at which time the endfrequency is reached in the sweep that is being generated, and that timeis noted (e.g., stored to memory). Then, because it may be known at theoutset that a sweep of a certain sweep length is desired, the ratio ofwhat the noted time is to the desired sweep length may be determined,and then β is multiplied by that ratio to determine the value of β forthe second run of the program. Then, the resulting sweep determined inthe second run will produce the desired result. Of course, in otherembodiments, the value of β to be used may be predetermined in any othersuitable way.

So, basically, the sweep generator device of one embodiment uses theabove equation (3) to determine the sweep rate versus frequency, inorder to produce a non-linear sweep rate that can be employed on aspecified hydraulic seismic device to achieve a target profile of theoutput spectrum desired in compliance with constraints (e.g., the fluidflow and mass displacement constraints) of the hydraulic seismic device.

It should be noted that sweep rate is the derivative of instantaneousfrequency, and frequency is the time derivative of the instantaneousphase. So, in order to generate a sweep, the instantaneous phase isneeded. Basically, the instantaneous phase is the double integral of thesweep rate. So, the instantaneous phase may be determined, which mayinclude some offset. For instance, a user may not want to start at zerophase, and so a phase offset may be added, such as an offset of 90degrees (π/2 radians). So, the sweep generator device may thennumerically double integrate the sweep rate versus frequency curve tocreate an instantaneous phase curve. Then, the sine of thatinstantaneous phase curve may be determined to result in a pilot orreference signal to be downloaded (or otherwise input) to the controlcircuitry of the hydraulic seismic vibrator device, and be used togenerate the sweep to be performed by the vibrator device.

In certain embodiments, the sweep generator may modify the very ends ofthe sweep a little bit through use of a taper of some kind, such as acosine taper on the ends, just to avoid having an abrupt start or stop.That taper could also be implemented in the frequency domain. Forinstance, this taper function may be input as part of the desired targetoutput spectrum, where the frequency sweep accounts for the desiredtaper.

An example SFC sweep designed for the case of an exemplary Model Avibrator is shown in FIG. 6. One thing to note, all things being equal,a heavier reaction mass will greatly reduce the dwell-time needed tobuild up the low-frequency end of the spectrum. In other words, if onevibrator needs to spend 25% of the sweep below 10-Hz to build up thelow-frequency sweep energy, and that vibrator is replaced with anothervibrator of identical design hut with a reaction mass say 30% heavier,this will reduce the necessary total low frequency dwell-time down toabout 15% of the total sweep time. This is because by increasing themass weight, the vibrator can effectively shake 30% harder than beforein the region where the first vibrator was constrained.

The three-stage-proportional-control four-way servovalve, such asdiscussed above with the example of FIG. 2, is the most common flowcontrol device in use today. A pilot valve through a torquemotorconverts the vibrator electronics to hydraulic flow and drives themain-stage spool. The main-stage spool directs flow into the actuatorchamber thereby accelerating the mass to generate the force required tomove the baseplate and the earth to which it is coupled. Most vibratorstoday use Moog “high-frequency” servovalve pilots that were firstintroduced in the 1980's. These pilot valves have an 18.9 liter/minuteflow rating.

Today, as a push is made toward higher frequencies with stifferbaseplate designs, the drive flow provided by the conventional pilotvalve can be insufficient to fully open the mainstage spool atfrequencies above 100-Hz. This problem becomes apparent duringhigh-frequency operation when the vibrator electronics warns that thetorquemotor current exceeds the manufacturer's rating. In the past,because the weighted sum estimate overestimated the ground force, thecontroller did not really drive the vibrator as hard as it should athigh-frequency. The weighted sum signal the controller uses forcomparison with the reference signal match spectrally, but in realitythe “true ground force” amplitude was falling off dramatically above100-Hz.

The relationships between valve opening, flow and the pressure dropacross the metered orifices is nonlinear giving rise to much of the oddharmonic distortion commonly seen in the field. FIG. 7A shows anexemplary servovalve main-stage 210 (as implemented in the exemplaryhydraulic seismic vibrator of FIG. 2), and FIG. 7B shows a correspondingschematic representation of the servovalve main-stage of FIG. 7A as abridge circuit. The nonlinear relationships between flow (Q) andpressure drop (P) across each orifice appear at the right in equations 4thru 7.

$\begin{matrix}{Q_{1} = {C_{d} \cdot A_{1} \cdot \sqrt{\frac{2}{\rho} \cdot \left( {P_{H} - P_{T}} \right)}}} & (4) \\{Q_{2} = {C_{d} \cdot A_{2} \cdot \sqrt{\frac{2}{\rho} \cdot \left( {P_{H} - P_{B}} \right)}}} & (5) \\{Q_{3} = {C_{d} \cdot A_{3} \cdot \sqrt{\frac{2}{\rho} \cdot \left( {P_{B} - P_{R}} \right)}}} & (6) \\{Q_{4} = {C_{d} \cdot A_{4} \cdot \sqrt{\frac{2}{\rho} \cdot \left( {P_{T} - P_{R}} \right)}}} & (7)\end{matrix}$

P_(H), P_(R), P_(T), and P_(B) represent respectively the supply highpressure, supply return pressure, pressure in the upper chamber of theactuator and the pressure in the lower chamber of the actuator. C_(d)represents the discharge coefficient for a sharp edged orifice which isassumed to be identical for all parts of the four-way mainstage valve.The terms A₁ . . . A₄ are the effective area of the orifice formedbetween each spool land and the sleeve slot. The slots are rectangularso that the orifice area changes linearly with spool position X_(v), butbecause the valve acts like a bridge circuit, if leakage terms areignored, only two areas are active at a time. So for example when X_(v)is positive (spool is down in FIG. 7A) only orifices 1 and 3 are activeand the area for orifices 2 and 4 is effectively zero.

If the servovalve is critically lapped, completely symmetric with noleakage, and the reaction mass is supported by a suspension system sothat the average pressure in the upper chamber and lower chamber of themass are the same, the equations 4-7 reduce to equation 8, where “k” isthe flow gain constant. Because the pressures inside the actuatorchambers are dynamic and not independent variables this equation is notsufficient to define the actuator output. It is one of several coupledequations that relate flow and actuator pressures.

$\begin{matrix}{Q_{L} = {k \cdot X_{V} \cdot \sqrt{\left( {P_{H} - P_{R}} \right) - {\frac{X_{V}}{X_{V}} \cdot \left( {P_{T} - P_{B}} \right)}}}} & (8)\end{matrix}$

As we move higher in frequency, the compressibility of the hydraulicfluid becomes an important factor. This causes an increase in flowdemand, but at the same time the differential pressure in the actuatoris high and approaches the supply pressure. This means there is nopressure left to drop across the servovalve to provide the necessaryflow. In some vibrator controllers this is flagged as an “overpressure”condition. This too is a limiting factor on high-frequency operation.

In one embodiment, a vibrator output force constraint profile may bedetermined which accounts for a plurality of different constraints, suchas fluid flow (or “pump”) constraint, mass displacement constraint, andpossibly other constraints, as examples. In one embodiment, the combinedvibrator output force constraint profile can be expressed mathematicallyas a function of frequency by an expression of the form:Fconstraint(f)=min[Fdisp(f),Fpump(f),Fvalve(f),Fset]  (9).

In this example, the combined vibrator output force constraint,Fconstraint(f), is determined as the minimum of the output forceconstraint imposed by the mass displacement (i.e., Fdisp(f)), the outputforce constraint imposed by the fluid flow or pump (i.e., Fpump(f)), theoutput force constraint imposed by the servo valve i.e., Fvalve(f)), andthe desired maximum force setting (i.e., Fset). It is recognized thatone could easily modify equation 9 to include environmental constraints.For example, the addition of another term Fenviron(f) could be easilyincluded as another argument in equation 9, where Fenviron(f) may imposea constraint on force output over a certain range of frequencies toavoid property damage or exciting resonance in a nearby structure.

When the above exemplary equation is employed by one embodiment of thesweep generator device for the exemplary Model A vibrator devicespecifications, the resulting peak force constraints over a range offrequencies as shown in FIG. 8 are determined, as are the followingrelationships:

F max  = 2.674 × 10⁵  Q max  = 9.697 × 10⁻³  Fv := 90Mr = 3.691 × 10³  X max  = 0.051Fdisp(f) := min [F max , [Mr ⋅ X max  ⋅ (f ⋅ 2 ⋅ π)²]]${{Fflow}(f)}:={9.87 \cdot f \cdot {Mr} \cdot \frac{Q\;\max}{Ap}}$${{Fvalve}(f)}:={{if}\mspace{14mu}\left( {{f > {Fv}},{F\;{\max \cdot \frac{Fv}{f}}},{F\;\max}} \right)}$Fset := 0.9 ⋅ F max 

Fset is set to be 90% of the hold-down force, which is labeled as Fmax(Newtons) in the above example. It is often desirable not to operate ata maximum peak force that exceeds this amount because it can lead todecoupling of the baseplate from the earth and result in excessiveharmonic distortion. Fdisp (Newtons) is the restriction imposed by theactuator stroke, where the term Xmax (meters) is set to one half of thepeak-to-peak stroke. Fflow is the constraint imposed by the pump ratingthat is rated for a maximum of Qmax meters³/second. Fvalve (Newtons) isthe high frequency limitation imposed by the scrvovalve, in this casethe corner was set at Fv=90 Hz.

According to certain embodiments, a target force profile (or “desiredtarget output spectrum”) may be received by the sweep generator device,and the sweep generator device may determine a sweep that may beemployed by a given hydraulic seismic vibrator device to produce thetarget force profile in compliance with various constraints of thevibrator device, such as by complying with Fconstraint(f)=min[Fdisp(f),Fpump(f), Fvalve(f), Fset] described above, where “min[ . . . ]” isequal to the minima of the arguments. As one example, let us assume aflat force output amplitude spectrum is desired to be output by thevibrator, which is down only 3-dB at 3 Hz and choose not to compensatefor the earth attenuation. An example of such desired flat three isshown graphically in FIG. 9. Further assume for this example that thedesired sweep range is to go from 3 to 123 Hz and the desired sweeplength is 20 seconds (or “20 s”). Again, FIG. 9 shows this exampletarget spectrum.

According to one embodiment, a sweep generator device receives, asinput, information defining the desired target output spectrum, and thesweep generator device determines a sweep that can be employed by thetarget hydraulic seismic vibrator device for producing the target outputspectrum in compliance with various constraints of the vibrator device.As discussed above, the sweep generator device may find the modifiedinstantaneous sweep rate “SR(f)” (Hz/s) as:SR(f)=β[F _(constraint)(f)/F _(target)(f)]² [F1−F0]/SL.In one embodiment, a value for β is selected (which may be determined asa result of a first run of the program, as discussed above), and theinstantaneous frequency (shown below as “Hz” and expressed in Hertz) andinstantaneous phase (shown below as φ and expressed in radians) for thesweep can be computed recursively as follows, where: “dt” is the timeincrement represented by each iteration, the index j=1 is the startingpoint, and j is incremented each iteration, and the recursion continuesuntil Hz_(j)=F1 where “N” is set to the total number of iterations, andif the value of β is chosen properly it follows that N·dt=SL. In otherwords, the product “j·dt” represents the time interval from the start ofthe sweep to step “j”.for j=1, . . . Nφ₀=0Hz ₀ :=F0Hz _(j) :=Hz _(j-1) +dt·SR(Hz _(j-1))φ_(j):=φ_(j-1) +dt·[2·π·(Hz _(j-1) +Hz _(j))·0.5]S _(j) =W _(j) sin(φ_(j))·Fconstraint(Hz _(j)).

If the user chooses to implement some form of phase offset to the sweepinstead of zero phase, one would set the initial phase to that value. Inone exemplary embodiment, “dt” is set to 0.0005 seconds, to correspondto the Sercel VE432 format (a model of vibrator controller in wide usetoday). The VE432 is a digital controller and the instantaneous valuesof the sweep array “S” can be downloaded from the computer used todesign the sweep into the VE432 memory where it is stored using a sampleinterval of “dt”. Later when the vibrator is commanded to sweep, thevibrator controller uses the stored values of “S” as the reference orpilot signal. In certain embodiments, the sweep generator may add to thevery ends of the sweep a little bit of a taper of some kind, such as acosine taper on the ends, just to avoid having an abrupt start orstop—this term is represented by “W” used in the formation of “S” shownabove.

As discussed above, the parameter “β” is a constant of proportionalitythat will be a function of the deviation away from a conventional linearsweep that is required. In this particular case being considered, β=1.38produced a sweep of 20 s length that had the desired start and endfrequencies. An example sweep designed for the case of an exemplaryModel A vibrator is shown in FIGS. 10 and 11, along with the resultingamplitude spectrum shown in FIG. 12. Note: amplitude end tapers wereapplied to the reference each of duration 250 ms.

The force target profile can be easily modified to incorporate featuresdesigned to mitigate the earth absorption effects. For example, if theexplorationist wants to boost the high frequency output to compensatefor this loss mechanism, one could alter the target spectrum to forexample incorporate a high frequency boost of 0.1 dB/Hz. As anotherexample, one may alter the target spectrum to correct for things likeambient noise. For example, if there is a lot of cultural noise thatfalls in the 5 to 10-Hz region, one could choose to increase the targetspectrum in that region thereby increasing the signal energy.

For the VE432 vibrator electronics, for example, usually the sweepdesign software is located on a laptop computer. There is a slot for aPCMCIA (Personal Computer Memory Card International Association) card inthe laptop and also a slot for this card in the VE432. The referencesweep array is downloaded onto the PCMCIA card in the laptop. The memorydevice is removed and then plugged into the VE432 and resides there. TheVE432 controller is connected to the vibrator system and upon commandproduces an electrical drive signal to drive the servovalve torquemotor.The output of the vibrator (usually ground force) is fed back to thecontroller where the vibrator output is compared to the reference signaland adjustments are made to the drive signal to compensate for thesystem response so that the vibrator output waveform matches thereference signal waveform as closely as system dynamics permit.Similarly, sweep design software of embodiments of the present inventionmay likewise be implemented in this manner, as an example.

FIG. 13 shows an exemplary system 1300 according to one embodiment ofthe present invention. System 1300 comprises a processor-based computingdevice, such as a personal computer (PC), laptop computer, servercomputer, workstation computer, etc. In this example, a sweep generatorsoftware application 1302 is executing on such a computer 1301.Accordingly, computer 1301 having sweep generator application 1302executing thereon provides an example of a sweep generator deviceaccording to certain embodiments of the present invention. While sweepgenerator application 1302 is shown as executing on computer 1301 forease of illustration in FIG. 13, it should be recognized that suchapplication 1302 may be residing and/or executing either locally oncomputer 1301 or on a remote computer to which computer 1301 iscommunicatively coupled via a communication network, such as a localarea network (LAN), the Internet or other wide area network (WAN), etc.In this embodiment, sweep generator application 1302 comprisescomputer-executable software code stored to a computer-readable mediumthat is readable by a processor of computer 1301 and, when executed bysuch processor, causes computer 1301 to perform the various operationsdescribed further herein for such sweep generator application 1302.

Sweep generator application 1302 may receive as input 1303 (e.g., viauser input to a user interface presented on a display of computer 1301by application 1302, via file transfer, or otherwise), manufacturerspecifications of one or more target seismic vibrator devices, such asthose specifications of a target seismic vibrator device 1306 that is tobe employed for seismic exploration. Examples of specifications that maybe received include those exemplary specifications shown in Table 1above. In certain embodiments, the manufacturer specifications of one ormore target seismic vibrator devices may be hard-coded into application1302, and/or the specifications may be read from a data storage location(e.g., from a file, etc.) by application 1302.

Sweep generator application 1302 may also receive as input 1304 (e.g.,via user input to a user interface presented on a display of computer1301 by application 1302, via file transfer, or otherwise), informationdefining a desired target output spectrum, such as the exemplary targetoutput spectrum shown in FIG. 9 above. In certain embodiments, theinformation defining a desired target output spectrum may be input by auser via user input devices, such as a keyboard, mouse, etc.) to a userinterface presented on a display of computer 1301 by application 1302,and/or the information may be read from a data storage location (e.g.,from a file, etc.) by application 1302.

Sweep generator application 1302 operates, as discussed further herein,to determine a frequency sweep 1305 that may be used on a target seismicvibrator device 1306 for producing the desired target output spectrum1304 in compliance with at least a fluid flow (or “pump”) constraintimposed by the target seismic vibrator device 1306. In certainembodiments, sweep generator application 1302 determines a frequencysweep 1305 that may be used on a target seismic vibrator device 1306 forproducing the desired target output spectrum 1304 in compliance with aplurality of different constraints imposed by the target seismicvibrator device 1306 or the operating environment 1309, such as bycomplying with Fconstraint(f)=min[Fdisp(f), Fpump(f), Fvalve(f), Fset,Fenviron(f)] described above.

The determined sweep 1305 that is generated by sweep generatorapplication 1302 may be stored as computer-readable data (e.g., in theform of any suitable data structure, such as a file, etc.), and may beinput to control logic 1307 of the target seismic vibrator device 1306.Control logic 1307 may be processor-based logic that is operable to readthe sweep 1305 and cause the hydraulic seismic vibrator device togenerate an output spectrum 1308 accordingly. Such control logic 1307that is commonly employed for hydraulic seismic vibrator devices iswell-known in the art, and any such control logic may be employed withembodiments of the present invention. That is, sweep generator 1302 maybe configured to produce its frequency sweep 1305 in any desired formatfor compatibility with any control logic implementation of a targetseismic vibrator device.

In certain embodiments, sweep generator application 1302 may evaluatemultiple target vibrator devices (e.g., using their respectivemanufacturer specifications received via input 1303) and produce afrequency sweep 1305 for each of the multiple target vibrator devices.Additionally or alternatively, sweep generator application 1302 mayselect a most appropriate one of the multiple vibrator devices, such asone that is most optimal because it can achieve the desired targetoutput spectrum 1304 by using a sweep 1305 that has a duration of adesired time period (e.g., the shortest time period). The sweepgenerator application 1302 may, in certain embodiments, be employed as asanity check to confirm which one or more of the target vibrator devicesunder consideration are operationally capable of achieving the desiredtarget output spectrum 1304, i.e., confirm which one or more of thedevices under evaluation are operationally capable (in compliance withits mechanical or hydraulic constraints) of supporting a sweep forachieving the desired target output spectrum 1304.

FIG. 14 shows an exemplary operational flow diagram according to oneembodiment of the present invention. In operational block 1401, a sweepgenerator application (e.g., application 1302 of FIG. 13) receivesinformation defining various manufacturer specifications (e.g.,specifications 1303 of FIG. 13, such as those exemplary specificationsincluded in Table 1 above) for a target seismic vibrator device (e.g.,seismic vibrator device 1306 of FIG. 13). The specifications may bereceived as input (e.g., via user input to a user interface presented ona display of computer 1301 by application 1302 of FIG. 13, via filetransfer, or otherwise). In certain embodiments, the manufacturerspecifications of one or more target seismic vibrator devices may behard-coded into sweep generator application 1302, and/or thespecifications may be read from a data storage location (e.g., from afile, etc.) by application 1302.

In operational block 1402, the sweep generator application may receiveinput defining constraints imposed upon the maximum output of thevibrator due to the operating environment (e.g., input 1309 of FIG. 13).For example, if the seismic survey is conducted in an area wherestructures are nearby, it may be desirable to limit the maximum outputof the vibrator over a certain frequency range thereby limiting themaximum amount of ground roll (surface wave energy) generated that mayinduce undesirable structural vibrations in nearby buildings, pipelinesor bridges. The environmental constraints may be received as input(e.g., via user input to a user interface presented on a display ofcomputer 1301 by application 1302 of FIG. 13, via file transfer, orotherwise).

In operational block 1403, the sweep generator application (e.g.,application 1302 of FIG. 13) receives input (e.g., input 1304 of FIG.13) defining a desired target output spectrum, such as the exemplarytarget output spectrum shown in FIG. 9 above. In certain embodiments,the information defining a desired target output spectrum may be inputby a user (via user input devices, such as a keyboard, mouse, etc.) to auser interface presented on a display of computer 1301 by application1302, and/or the information may be read from a data storage location(e.g., from a file, etc.) by application 1302. The information definingthe desired target output spectrum may include information specifying,for example, one or more of a force amplitude spectrum to be output bythe vibrator device (such as the exemplary flat force output amplitudespectrum in the example of FIG. 9), a desired sweep range (such as theexemplary range of 3 Hz to 123 Hz in the example of FIG. 9), and adesired sweep length (such as the exemplary sweep length of 20 secondsin the example discussed above with FIG. 9).

In operational block 1404, the sweep generator application determines afrequency sweep to achieve the desired target output spectrum incompliance with multiple constraints imposed by the target seismicvibrator device. As discussed further herein, such determined frequencysweep may be a nonlinear frequency sweep. Further, as described furtherherein, the sweep generator application determines the multipleconstraints imposed by the target seismic vibrator device based at leastin part on the manufacturer specifications received in block 1401. Asshown in block 1405, the sweep generator application determines a massdisplacement constraint imposed by the target seismic vibrator device,in this illustrative embodiment. Further, in block 1406, the sweepgenerator application determines a pump flow (or “fluid flow”)constraint imposed by the target seismic vibrator device, in thisillustrative embodiment. In block 1407, the sweep generator applicationdetermines the frequency sweep to achieve the desired target outputspectrum (defined in the information received in block 1403) incompliance with the determined mass displacement constraint and pumpflow constraint of the target seismic vibrator device. Of course, asdiscussed further herein, various other constraints in addition to themass displacement and pump flow constraints may also be taken intoconsideration by the sweep generator application. For instance, thesweep generator application may employ Fconstraint(f)=min[Fdisp(f),Fpump(f), Fvalve(f), Fenviron(f), Fset], as described above, in certainembodiments to determine a frequency sweep that achieves the desiredtarget output spectrum in compliance with the various constraintsrepresented by Fdisp, Fpump, Fvalve, Fenviron, and Fset.

Information defining the determined frequency sweep may be stored by thesweep generator application to computer-readable medium, and thatinformation may then be input (e.g., via a computer network, user input,read from a file, read from a memory storage device, or otherwise) tocontrol logic 1307 of the target seismic vibrator device. Accordingly,as shown in operational block 1408, the determined frequency sweep maythen be employed on the target seismic vibrator device (e.g., used bycontrol logic 1307) for performing seismic exploration (e.g.,vibroseis).

The following is an exemplary discussion of one application of anembodiment of the present invention (developed using the MathCadprogram) for creating some very low frequency sweeps. This example ismerely for illustrative purposes for one exemplary application, and isnot intended to be limiting on the above-described concepts in any way.

First, various variables are initialized, as follows:

F0:=1, start frequency in Hz;

F1:=80, end frequency in Hz;

SL:=30, sweep length in seconds;

Fcorner:=F0, a half-power corner frequency (Hz);

TL:=0.1, the duration of the start and end cosine tapers in seconds;

φ₀=0, the phase offset in radians;

dt=0.0005, the sample interval (seconds).

Then the specification parameters for the particular vibrator model areentered:

Fmax=267400, the holddown force (N);

Mr=3500, the reaction mass size (kg);

Xmax=0.0508, the peak mass stroke (m);

Qmax=0.0097, the pump rated flow (m³/s);

Ap=0.0133, the actuator piston area (m²)

In the above, Xmax is the maximum useable peak stroke (m) for the ModelA and Qmax is die maximum average flow m^3/s, and Fmax is the maximumforce (N). Then, the following computations are performed:

Fdisp  (f) := min [F max , [Mr ⋅ X max  ⋅ (f ⋅ 2 ⋅ π)²]]${{Fflow}\mspace{11mu}(f)}:={9.87 \cdot f \cdot {Mr} \cdot {\frac{Q\;\max}{Ap}.}}$

The term “Mr·Xmax·(f·2·π)²” represents the maximum sinusoidal force thatcould be created by the actuator at low frequency if the mass was driven+/−Xmax; i.e. full stroke. This follows from Newtons second law ofmotion. The term “Xmax·(f·2π)²” is the peak acceleration and Mr is thereaction mass size, since we are dealing with sinusoids and accelerationis the second derivative with respect to time of the displacement. Inthis example, there are no environmental constraints considered.

Now, the maximum force is limited to the combined constraints of massdisplacement, fluid flow and desired maximum force setting (Fset), asfollows:Fset:=0.9·FmaxFset=2.406×10⁵Fconstraint(f):=min(Fdisp(f),Fflow(f),Fset)

The constraints on force that are imposed over a range of frequencies inthis example is illustrated in the graph of FIG. 15. The graph shown isof the aforementioned function Fconstraint(f) versus frequency.

Now, an β value is chosen so that the sweep being generated ends up atF1 at a time corresponding to SL.

n := 2${{Target}(f)}:={{if}\mspace{14mu}\left\lbrack {{{F\; 0} \leq f \leq {F\; 1}},\frac{\left( \frac{f}{Fcorner} \right)^{n}}{\sqrt{\left\lbrack {1 + \left( \frac{f}{Fcorner} \right)^{2 \cdot n}} \right\rbrack}},10^{- 2}} \right\rbrack}$

The resulting target spectrum is illustrated for this example in thegraph of FIG. 16, with a zoom on the portion of the curve extending from0 to 10-Hz.

From a previous run it was determined that:β=5.69 and N=60,000.

The sweep rate “SR” as a function of instantaneous frequency “f” in Hzis given by:SR(f)=[Fconstraint(f)/(Fmax·Target(f)]² [F1−F0)/SL]·β, for F0≦f≦F1;otherwise 0

A cosine taper window function was selected to define a vector of length“N+1” called “W” with FIG. 17 providing a graphical depiction.

The instantaneous frequency and phase were computed recursively asfollows:For j=1 . . . Nφ₀=0Hz ₀ :=F0Hz _(j) :=Hz _(j-1) dt·SR(Hz _(j-1))φ_(j):=φ_(j-1) +dt·[2·π·(Hz _(j-1) +Hz _(j))0.5]S _(j) =W _(j) sin(φ_(j))·Fconstraint(Hz _(j)).

FIG. 18 displays the resultant instantaneous frequency versus timefunction. As can be seen a considerable amount of time is spent below 5Hz, about 23 seconds of the 30 second sweep length is spent there tobuild up the energy at the low frequencies in order to compensate forthe low force output of the vibrator through the range of frequencies 1to 5 Hz. This amount of dwell time at these low frequencies would not bepossible unless the pump flow constraint was observed.

FIG. 19 displays the resultant signal “S” (reference signal) vs. timeexpressed as a force in Newtons. Again the low amplitude of the signalis obvious through about the first 23 seconds of the sweep.

As a check on the properties of the frequency sweep “S”, the referencesignal was autocorrelated to detect any anomalies that might produceexcessive sidelobe levels. In particular we want to check that sidelobelevels trail off as we move away from zero lag. High sidelobe levels canmask deep reflection events. The magnitude of the autocorrelation “RA”expressed in decibels appears in FIG. 20. The autocorrelation functionwas computed in the frequency domain and is symmetric about time zero,but because the autocorrelation was computed in the frequency domainusing a fast fourier transform method there is a “wraparound effect”that is well known to those skilled in the art so time lag values appearat the right.

FIG. 21 shows the resulting spectral density of the sweep “S” plotted ona decibel scale versus frequency displayed on a logarithmic scale. Theresultant spectrum closely approximates the desired target spectrum withsome Gibb's phenomenon effects occurring near the start and endfrequencies due to the very short taper length that was applied. Ingeneral, use of a longer taper length would have reduced this rippleeffect.

Embodiments, or portions thereof, may be embodied in program or codesegments operable upon a processor-based system (e.g., computer system)for performing functions and operations as described herein fordetermining a frequency sweep (such as sweep 1305 of FIG. 13) forachieving a desired target output spectrum (e.g., spectrum 1304 of FIG.13) in compliance with constraint(s) of a target hydraulic seismicvibrator device, such as fluid flow and mass displacement constraints.The program or code segments making up the various embodiments may bestored in a computer-readable medium, which may comprise any suitablemedium for temporarily or permanently storing such code. Examples of thecomputer-readable medium include such physical computer-readable mediaas an electronic memory circuit, a semiconductor memory device, randomaccess memory (RAM), read only memory (ROM), erasable ROM (EROM), flashmemory, a magnetic storage device (e.g., floppy diskette), opticalstorage device (e.g., compact disk (CD), digital versatile disk (DVD),etc.), a hard disk, and the like. The software program may beimplemented as a sweep generator application 1302, such as describedabove with FIG. 13.

FIG. 22 illustrates an exemplary computer system 2200 on which softwarefor performing operations described above for determining a frequencysweep according to embodiments of the present invention may beimplemented. Central processing unit (CPU) 2201 is coupled to system bus2202. While a single CPU 2201 is illustrated, it should be recognizedthat computer system 2200 may comprise a plurality of processing units(e.g., CPUs 2201) to be employed for parallel computing. CPU(s) 2201 maybe any general-purpose CPU(s). The present invention is not restrictedby the architecture of CPU(s) 2201 (or other components of exemplarysystem 2200) as long as CPU(s) 2201 (and other components of system2200) supports the inventive operations as described herein. CPU(s) 2201may execute the various logical instructions according to embodimentsdescribed above. For example, CPU(s) 2201 may execute machine-levelinstructions for performing processing of the sweep generatorapplication described above, such as for the exemplary operational flowof FIG. 14.

Computer system 2200 also preferably includes random access memory (RAM)2203, which may be SRAM, DRAM, SDRAM, or the like. Computer system 2200preferably includes read-only memory (ROM) 2204 which may be PROM,EPROM, EEPROM, or the like. RAM 2203 and ROM 2204 hold user and systemdata and programs, as is well known in the art.

Computer system 2200 also preferably includes input/output (I/O) adapter2205, communications adapter 2211, user interface adapter 2208, anddisplay adapter 2209. I/O adapter 2205, user interface adapter 2208,and/or communications adapter 2211 may, in certain embodiments, enable auser to interact with computer system 2200 in order to inputinformation.

I/O adapter 2205 preferably connects to storage device(s) 2206, such asone or more of hard drive, compact disc (CD) drive, floppy disk drive,tape drive, etc. to computer system 2200. The storage devices may beutilized when RAM 2203 is insufficient for the memory requirementsassociated with storing data for operations of embodiments of thepresent invention. The data storage of computer system 2200 may be usedfor storing such information as received manufacturer specifications ofone or more seismic vibrator devices (e.g., specifications 1303 of FIG.13), received information defining a maximum force that can be utilizedover a certain range of frequencies due to environmental impactconcerns, received information defining a desired target output spectrum(e.g., information 1304 of FIG. 13), a generated frequency sweep (e.g.,sweep 1305 of FIG. 13), and/or other data used or generated inaccordance with embodiments of the present invention. Communicationsadapter 2211 is preferably adapted to couple computer system 2200 tonetwork 2212, which may enable information to be input to and/or outputfrom system 2200 via such network 2212 (e.g., the Internet or otherwide-area network, a local-area network, a public or private switchedtelephony network, a wireless network, any combination of theforegoing). User interface adapter 2208 couples user input devices, suchas keyboard 2213, pointing device 2207, and microphone 2214 and/oroutput devices, such as speaker(s) 2215 to computer system 2200. Displayadapter 2209 is driven by CPU(s) 2201 to control the display on displaydevice 2210 to, for example, display a user interface of sweep generatorapplication 1302 for receiving information, such as information 1303and/or 1304 from a user, according to certain embodiments.

It shall be appreciated that the present invention is not limited to thearchitecture of system 2200. For example, any suitable processor-baseddevice may be utilized for implementing all or a portion of embodimentsof the present invention, including without limitation personalcomputers, laptop computers, computer workstations, servers, and/orother multi-processor computing devices. Moreover, embodiments may beimplemented on application specific integrated circuits (ASICs) or verylarge scale integrated (VLSI) circuits. In fact, persons of ordinaryskill in the art may utilize any number of suitable structures capableof executing logical operations according to the embodiments.

It shall also be appreciated that the present invention is not limitedto use with hydraulic vibrator devices. Seismic vibrators equipped withelectric actuators are subject to similar constraints. For example theremay be certain voltage and current limitations on electric seismicvibrators as well as stroke limitations imposed either by the poweramplifier used to drive them, or the power supply, or an upper limit onpeak current may be determined by other factors like degaussing ofmagnets, thermal issues or current rating for wires in electromagnets.The useable upper limit on the voltage supplied to drive the vibratormay be determined by the power supply or even voltage limits on wireinsulation. Embodiments of the present invention may, accordingly, beimplemented consistent with the concepts described above to accommodateconstraints imposed by electric seismic vibrators to generate sweepsthat meet a target spectral density subject to constraints imposed bythe electrical vibratory system.

Although the present invention and its advantages have been described indetail, it should be understood that various changes, substitutions andalterations can be made herein without departing from the spirit andscope of the invention as defined by the appended claims. Moreover, thescope of the present application is not intended to be limited to theparticular embodiments of the process, machine, manufacture, compositionof matter, means, methods and steps described in the specification. Asone of ordinary skill in the art will readily appreciate from thedisclosure of the present invention, processes, machines, manufacture,compositions of matter, means, methods, or steps, presently existing orlater to be developed that perform substantially the same function orachieve substantially the same result as the corresponding embodimentsdescribed herein may be utilized according to the present invention.Accordingly, the appended claims are intended to include within theirscope such processes, machines, manufacture, compositions of matter,means, methods, or steps.

The invention claimed is:
 1. A method for generating a target outputspectrum for use in seismic exploration to be achieved by a hydraulicseismic vibrator device, the method comprising: receiving constraintinformation related to the hydraulic seismic vibrator device; using amathematical relationship for achieving the target output spectrum,wherein the mathematical relationship relates the (i) the constraintinformation of the hydraulic seismic vibrator device, (ii) the targetoutput spectrum, and (iii) a frequency sweep rate; and determining in aprocessor-based device, based on the mathematical relationship, afrequency sweep for achieving the target output spectrum by thehydraulic seismic vibrator device in compliance with the constraintinformation of the hydraulic seismic vibrator device, wherein themathematical relationship is given by:SR(f)=β·[F_(constraint)(f)/F _(target)(f)]² ·[F1−F0]/SL, where f is aninstantaneous frequency, SL is a sweep length with a start frequency F0and an end frequency F1, F_(target)(f) is the target output spectrum,F_(constraint)(f) is a force constraint related to the constraintinformation, SR(f) is the frequency sweep rate, and β is a constant. 2.The method of claim 1, further comprising: employing said determinedfrequency sweep by said hydraulic seismic vibrator device for generatingsaid target output spectrum.
 3. The method of claim 1, wherein saidfrequency sweep comprises a nonlinear frequency sweep.
 4. The method ofclaim 1, wherein said determining comprises: determining, based onspecifications of said hydraulic seismic vibrator device, a fluid flowconstraint that is imposed.
 5. The method of claim 1, furthercomprising: receiving specifications of one or more hydraulic seismicvibrator devices.
 6. The method of claim 5, wherein the specificationscomprise one or more of: holddown force; reaction mass size; peak massstroke; pump rated flow; servovalve opening; and actuator piston area.7. The method of claim 1, wherein said determining said frequency sweepcomprises: determining said frequency sweep for achieving said targetoutput spectrum by said hydraulic seismic vibrator device in compliancewith a plurality of different constraints imposed by said hydraulicseismic vibrator device.
 8. The method of claim 7, wherein saidplurality of different constraints comprise a fluid flow constraint andat least one of mass displacement constraint, output force constraintimposed by a servo valve, and a desired maximum force setting.
 9. Themethod of claim 1, wherein said constraint information comprise a fluidflow constraint and a mass displacement constraint.
 10. The method ofclaim 1, wherein said determining said frequency sweep comprises:determining said frequency sweep for achieving said target outputspectrum by said hydraulic seismic vibrator device in compliance with aplurality of different constraints.
 11. The method of claim 10, whereinsaid plurality of different constraints comprise: at least oneoperational constraint imposed by said hydraulic seismic vibratordevice.
 12. The method of claim 10, wherein said plurality of differentconstraints comprise at least one environmental constraint that limitsforce output over a range of frequencies to avoid property damage orexciting resonance in a structure within a location at which thehydraulic seismic vibrator device is to be employed.
 13. A method forcalculating a target output spectrum to be achieved by a vibratordevice, the method comprising: receiving constraint information relatedto the vibrator device; using a mathematical relationship for achievingthe target output spectrum, wherein the mathematical relationshiprelates the (i) the constraint information of the vibrator device, (ii)the target output spectrum, and (iii) a frequency sweep rate; anddetermining, based on the mathematical relationship, a frequency sweepfor achieving the target output spectrum by the vibrator device incompliance with the constraint information of the vibrator device,wherein said receiving, said using, and said determining are performedby a processor-based device, and wherein the mathematical relationshipis given by:SR(f)=β·[F_(constraint)(f)/F _(target)(f)]² ·[F1−F0]/SL, where f is aninstantaneous frequency, SL is a sweep length with a start frequency F0and an end frequency F1, F_(target)(f) is the target output spectrum,F_(constraint)(f) is a force constraint related to the constraintinformation, SR(f) is the frequency sweep rate, and β is a constant. 14.The method of claim 13, further comprising: receiving specifications ofsaid vibrator device, wherein said specifications comprise one or moreof, holddown force; reaction mass size; peak mass stroke; pump ratedflow; servovalve opening; and actuator piston area.
 15. The method ofclaim 13, wherein said determining step comprises: determining thefrequency sweep for achieving said target output spectrum by a hydraulicseismic vibrator device in compliance with a fluid flow constraint andat least one of mass displacement constraint, output force constraintimposed by a servo valve, and a desired maximum force setting.
 16. Themethod of claim 13, wherein said determining step comprises: determiningthe frequency sweep for achieving said target output spectrum by ahydraulic seismic vibrator device in compliance with a fluid flowconstraint and at least one environmental constraint that limits a forceoutput over a range of frequencies to avoid property damage or excitingresonance in a structure within a location at which the hydraulicseismic vibrator device is to be employed.
 17. A computer device forgenerating a target output spectrum for use in seismic exploration to beachieved by a vibrator device, the computer device comprising: aninterface configured to receive constraint information related to thehydraulic seismic vibrator device; and a processor connected to theinterface and configured to, use a mathematical relationship forachieving the target output spectrum, wherein the mathematicalrelationship relates the (i) the constraint information of the vibratordevice, (ii) the target output spectrum, and (iii) a frequency sweeprate; and determine, based on the mathematical relationship, a frequencysweep for achieving the target output spectrum by the vibrator device incompliance with the constraint information of the vibrator device,wherein the mathematical relationship is given by,SR(f)=β·[F_(constraint)(f)/F _(target)(f)]² ·[F1−F0]/SL, where f is aninstantaneous frequency, SL is a sweep length with a start frequency F0and an end frequency F1, F_(target)(f) is the target output spectrum,F_(constraint)(f) is a force constraint related to the constraintinformation, SR(f) is the frequency sweep rate, and β is a constant.